Mobile fracturing pump transport for hydraulic fracturing of subsurface geological formations

ABSTRACT

Providing pressurized fracturing fluid with a fracturing pump transport comprising a first fracturing pump and a second fracturing pump that are coupled on opposite sides of a dual shaft electric motor. A first drive line assembly comprising a first engagement coupling that allows for selective engagement and/or disengagement of the first fracturing pump with the dual shaft electric motor. A second drive line assembly comprising a second engagement coupling that allows for selective engagement and/or disengagement of the second fracturing pump with the dual shaft electric motor. The fracturing pump transport also comprising an engagement panel that allows for selective engagement or disengagement at the first engagement coupling based on receiving a remote command.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in part of U.S. patent applicationSer. No. 14/971,450, filed Dec. 16, 2015 by Jeffrey G. Morris et al. andentitled “Mobile Electric Power Generation for Hydraulic Fracturing ofSubsurface Geological Formations, which claims the benefit of U.S.Provisional Patent Application No. 62/094,773, filed Dec. 19, 2014 byJeffrey G. Morris et al. and entitled “Mobile Electric Power Generationand Electrically Powered Hydraulic Fracturing of UndergroundFormations,” all of which are hereby incorporated by reference as ifreproduced in their entirety.

BACKGROUND

Hydraulic fracturing has been commonly used by the oil and gas industryto stimulate production of hydrocarbon wells, such as oil and/or gaswells. Hydraulic fracturing, sometimes called “fracing” or “fracking” isthe process of injecting fracturing fluid, which is typically a mixtureof water, sand, and chemicals, into the subsurface to fracture thesubsurface geological formations and release otherwise encapsulatedhydrocarbon reserves. The fracturing fluid is typically pumped into awellbore at a relatively high pressure sufficient to cause fissureswithin the underground geological formations. Specifically, once insidethe wellbore, the pressurized fracturing fluid is pressure pumped downand then out into the subsurface geological formation to fracture theunderground formation. A fluid mixture that may include water, variouschemical additives, and proppants (e.g., sand or ceramic materials) canbe pumped into the underground formation to fracture and promote theextraction of the hydrocarbon reserves, such as oil and/or gas. Forexample, the fracturing fluid may comprise a liquid petroleum gas,linear gelled water, gelled water, gelled oil, slick water, slick oil,poly emulsion, foam/emulsion, liquid carbon dioxide (CO₂), nitrogen gas(N₂), and/or binary fluid and acid.

Implementing large-scale fracturing operations at well sites typicallyrequires extensive investment in equipment, labor, and fuel. Forinstance, a typical fracturing operation uses a variety of fracturingequipment, numerous personnel to operate and maintain the fracturingequipment, relatively large amounts of fuel to power the fracturingoperations, and relatively large volumes of fracturing fluids. As such,planning for fracturing operations is often complex and encompasses avariety of logistical challenges that include minimizing the on-sitearea or “footprint” of the fracturing operations, providing adequatepower and/or fuel to continuously power the fracturing operations,increasing the efficiency of the hydraulic fracturing equipment, andreducing any environmental impact resulting from fracturing operations.Thus, numerous innovations and improvements of existing fracturingtechnology are needed to address the variety of complex and logisticalchallenges faced in today's fracturing operations.

SUMMARY

The following presents a simplified summary of the disclosed subjectmatter in order to provide a basic understanding of some aspects of thesubject matter disclosed herein. This summary is not an exhaustiveoverview of the technology disclosed herein. It is not intended toidentify key or critical elements of the invention or to delineate thescope of the invention. Its sole purpose is to present some concepts ina simplified form as a prelude to the more detailed description that isdiscussed later.

A system for pumping and pressurizing fracturing fluid, the systemcomprising: a mobile transport, an electric prime mover that comprises ashaft and mounted on the mobile transport, a drive line assembly, afracturing pump mounted on the mobile transport that is coupled to anend of the shaft via the drive line assembly. The drive line assemblycomprises an engagement coupling configured to selectively engage and/ordisengage the fracturing pump and the electric prime mover, and anengagement panel mounted on the mobile transport and configured toreceive a remote command and trigger, in response to the remote command,engagement and/or disengagement of the fracturing pump and the electricprime mover.

A fracturing pump transport comprising: a first fracturing pump, asecond fracturing pump, a dual shaft electric motor that comprises ashaft having a first end and a second end, a first drive line assemblythat comprises a first engagement coupling that allows for selectiveengagement and/or disengagement of the first fracturing pump with thefirst end of the shaft, a second drive line assembly that comprises asecond engagement coupling that allows for selective engagement and/ordisengagement of the second fracturing pump with the second end of theshaft, and an engagement panel that allows for selective engagementand/or disengagement at the first engagement coupling, selectiveengagement and/or disengagement of at the second engagement coupling, orboth based on receiving a remote command.

A method for pumping and pressurizing fracturing fluid, the methodcomprising: receiving an engagement and/or disengagement command from alocation remote to a fracturing pump transport, engaging and/ordis-engaging, in response to receiving the engagement command, a firstfracturing pump mounted on the fracturing pump transport with a dualshaft electric prime mover mounted on the fracturing pump transportusing a first drive line assembly, wherein the first drive line assemblycomprises an engagement coupling that allows for selective engagementbetween the first fracturing pump and the dual shaft electric primemover, and driving a second fracturing pump mounted on the fracturingpump transport with the dual shaft electric prime mover after eitherengaging and/or disengaging the first fracturing pump from the dualshaft electric prime mover using the first drive line assembly.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of this disclosure, reference is nowmade to the following brief description, taken in connection with theaccompanying drawings and detailed description, wherein like referencenumerals represent like parts.

FIG. 1 is a schematic diagram of an embodiment of a well site, wherevarious embodiments may operate within.

FIG. 2 is a schematic diagram an embodiment of a well site that includesa mobile source of electricity that comprises three transports for amobile fracturing system.

FIG. 3 is a schematic diagram an embodiment of a well site that includestwo wellheads and two data vans.

FIG. 4A is a schematic diagram of an embodiment of the gas turbinegenerator transport.

FIG. 4B is a schematic diagram of an embodiment of the gas turbinegenerator transport.

FIG. 5A is a schematic diagram of an embodiment of an inlet and exhausttransport.

FIG. 5B is a schematic diagram of an embodiment of an inlet and exhausttransport.

FIG. 5C is a schematic diagram of an embodiment of an inlet and exhausttransport that includes a sliding air inlet filter housing.

FIG. 6 is a schematic diagram of an embodiment of the two transportmobile electric power source when in operational mode.

FIG. 7A is a schematic diagram of an embodiment of a fracturing pumptransport powered by the mobile source of electricity.

FIG. 7B is a schematic diagram of an embodiment of a fracturing pumptransport powered by the mobile source of electricity.

FIG. 8A is a schematic diagram of an embodiment of a blender transportthat includes an electric blender.

FIG. 8B is a schematic diagram of an embodiment of a blender transportthat includes an electric blender.

FIG. 9A of an embodiment of a blender transport that includes anelectric blender with enclosed mixer hoppers.

FIG. 9B of an embodiment of a blender transport that includes anelectric blender with enclosed mixer hoppers.

FIG. 10 is a schematic diagram of an embodiment of a control networksystem used to monitor, control, and communicate with a variety ofcontrol systems located at one or more well sites.

FIG. 11 is a flow chart of an embodiment of a method to provide a mobilesource of electricity for fracturing operations.

FIG. 12 is a flow chart of an embodiment of a method to pump fracturingfluid into a wellhead.

FIG. 13 is a schematic diagram of an embodiment of a fracturing pumptransport configured to remotely engage and/or disengage one or morepumps from the prime mover.

FIG. 14A is a schematic diagram of an embodiment of a drive lineassembly that includes an engagement coupling located in an engagementposition.

FIG. 14B is a schematic diagram of an embodiment of a drive lineassembly that includes an engagement coupling located in a disengagementposition.

FIG. 15A is a schematic diagram of an embodiment of an engagement panelconfigured to cause remote engagement and/or disengagement of one ormore pumps with a prime mover.

FIG. 15B is a schematic diagram of an embodiment of a hydraulic controlbank located within an engagement panel.

While certain embodiments will be described in connection with theillustrative embodiments shown herein, the invention is not limited tothose embodiments. On the contrary, all alternatives, modifications, andequivalents are included within the spirit and scope of the invention asdefined by the claims. In the drawing figures, which are not to scale,the same reference numerals are used throughout the description and inthe drawing figures for components and elements having the samestructure, and primed reference numerals are used for components andelements having a similar function and construction to those componentsand elements having the same unprimed reference numerals.

DETAILED DESCRIPTION

As used herein, the term “transport” refers to any transportationassembly, including, but not limited to, a trailer, truck, skid, and/orbarge used to transport relatively heavy structures, such as fracturingequipment.

As used herein, the term “trailer” refers to a transportation assemblyused to transport relatively heavy structures, such as fracturingequipment that can be attached and/or detached from a transportationvehicle used to pull or move the trailer. In one embodiment, the trailermay include the mounts and manifold systems to connect the trailer toother fracturing equipment within a fracturing system or fleet.

As used herein, the term “lay-down trailer” refers to a trailer thatincludes two sections with different vertical heights. One of thesections or the upper section is positioned at or above the traileraxles and another section or the lower section is positioned at or belowthe trailer axles. In one embodiment the main trailer beams of thelay-down trailer may be resting on the ground when in operational modeand/or when uncoupled from a transportation vehicle, such as a tractor.

As used herein, the term “gas turbine generator” refers to both the gasturbine and the generator sections of a gas-turbine generator transport.The gas turbine generator receives hydrocarbon fuel, such as naturalgas, and converts the hydrocarbon fuel into electricity.

As used herein, the term “inlet plenum” may be interchanged andgenerally referred to as “inlet”, “air intake,” and “intake plenum,”throughout this disclosure. Additionally, the term “exhaust collector”may be interchanged throughout and generally referred to as “exhaustdiffuser” and “exhaust plenum” throughout this disclosure.

As used herein, the term “gas turbine inlet filter” may be interchangedand generally referred to as “inlet filter” and “inlet filter assembly.”The term “air inlet filter housing” may also be interchanged andgenerally referred to as “filter housing” and “air filter assemblyhousing” throughout this disclosure. Furthermore, the term “exhauststack” may also be interchanged and generally referred to as “turbineexhaust stack” throughout this disclosure.

Various example embodiments are disclosed herein that provide mobileelectric fracturing operations for one or more well sites. To providefracturing operations, a mobile source of electricity may be configuredto provide electric power to a variety of fracturing equipment locatedat the well sites. The mobile source of electricity may be implementedusing at least two transports to reduce its “footprint” at a site. Onetransport, the power generation transport, may comprise a gas turbineand generator along with ancillary equipment that supplies electricpower to the well sites. For example, the power generation transport mayproduce electric power in the ranges of about 15-35 megawatt (MW) whenproviding electric power to a single well site. A second transport, theinlet and exhaust transport, may comprise one or more gas turbine inletair filters and a gas turbine exhaust stack. The power generationtransport and the inlet and exhaust transport may be arranged such thatthe inlet and exhaust are connected at the side of the gas turbineenclosure rather than through the top of the gas turbine enclosure. Inone embodiment, the mobile source of electricity may comprise a thirdsupplemental transport, an auxiliary gas turbine generator transport,that provides power to ignite, start, or power on the power generationtransport and/or provide ancillary power where peak electric powerdemand exceeds the electric power output of the gas turbine generatortransport. The auxiliary gas turbine generator transport may comprise asmaller gas turbine generator than the one used in the power generationtransport (e.g., provides about 1-8 MW of electric power).

Also disclosed herein are various example embodiments of implementingmobile fracturing operations using a fracturing pump transport thatcomprises a dual shaft electric motor configured to drive at least twopumps. The dual shaft electric motor may be an electric motor configuredto operate within a desired mechanical power range, such as about 1,500horsepower (HP) to about 10,000 HP. Each of the pumps may be configuredto operate within a desired mechanical power range, such as about 1,500HP to about 5,000 HP, to discharge fracturing fluid at relatively highpressures (e.g., about 10,000 pounds per square inch (PSI)). In oneembodiment, the pumps may be plunger-style pumps that comprise one ormore plungers to generate the high-pressure fracturing fluid. Thefracturing pump transport may mount and couple the dual shaft electricmotor to the pumps using sub-assemblies that isolate and allow operatorsto remove the pumps and/or the dual shaft electric motor individuallyand without disconnecting the fracturing pump transport from the mobilefracturing system.

The disclosure also includes various example embodiments of a controlnetwork system that monitors and controls one or more hydraulicfracturing equipment remotely. The different fracturing equipment, whichinclude, but are not limited to, a blender, hydration unit, sandhandling equipment, chemical additive system, and the mobile source ofelectricity, may be configured to operate remotely using a networktopology, such as an Ethernet ring topology network. The control networksystem may remove implementing control stations located on and/or inclose proximity to the fracturing equipment. Instead, a designatedlocation, such as a data van and/or a remote location away from thevicinity of the fracturing equipment may remotely control the hydraulicfracturing equipment.

FIG. 1 is a schematic diagram of an embodiment of a well site 100 thatcomprises a wellhead 101 and a mobile fracturing system 103. Generally,a mobile fracturing system 103 may perform fracturing operations tocomplete a well and/or transform a drilled well into a production well.For example, the well site 100 may be a site where operators are in theprocess of drilling and completing a well. Operators may start the wellcompletion process with vertical drilling, running production casing,and cementing within the wellbore. The operators may also insert avariety of downhole tools into the wellbore and/or as part of a toolstring used to drill the wellbore. After the operators drill the well toa certain depth, a horizontal portion of the well may also be drilledand subsequently encased in cement. The operators may be subsequentlypack the rig, and a mobile fracturing system 103 may be moved onto thewell site 100 to perform fracturing operations that force relativelyhigh pressure fracturing fluid through wellhead 101 into subsurfacegeological formations to create fissures and cracks within the rock. Thefracturing system 103 may be moved off the well site 100 once theoperators complete fracturing operations. Typically, fracturingoperations for well site 100 may last several days.

To provide an environmentally cleaner and more transportable fracturingfleet, the mobile fracturing system 103 may comprise a mobile source ofelectricity 102 configured to generate electricity by convertinghydrocarbon fuel, such as natural gas, obtained from one or more othersources (e.g., a producing wellhead) at well site 100, from a remoteoffsite location, and/or another relatively convenient location near themobile source of electricity 102. Improving mobility of the mobilefracturing system 103 may be beneficial because fracturing operations ata well site typically last for several days and the fracturing equipmentis subsequently removed from the well site after completing thefracturing operation. Rather than using fuel that significantly impactsair quality (e.g., diesel fuel) as a source of power and/or receivingelectric power from a grid or other type of stationary power generationfacility (e.g., located at the well site or offsite), the mobilefracturing system 103 utilizes a mobile source of electricity 102 as apower source that burns cleaner while being transportable along withother fracturing equipment. The generated electricity from the mobilesource of electricity 102 may be supplied to fracturing equipment topower fracturing operations at one or more well sites. As shown in FIG.1, the mobile source of electricity 102 may be implemented using twotransports in order to reduce the well site footprint and the abilityfor operators to move the mobile source of electricity 102 to differentwell sites and/or different fracturing jobs. Details regardingimplementing the mobile source of electricity 102 are discussed in moredetail in FIGS. 4A-6.

The mobile source of electricity 102 may supply electric power tofracturing equipment within the mobile fracturing system 103 that mayinclude, but is not limited to, at least one switch gear transport 112,a plurality of drive power transports 104, at least one auxiliary powertransport 106, at least one blender transport 110, at least one data van114 and a plurality of fracturing pump transports 108 that deliverfracturing fluid through wellhead 101 to subsurface geologicalformations. The switch gear transport 112 may receive the electricitygenerated from the mobile source of electric power 102 via one or moreelectrical connections. In one embodiment, the switch gear transport 112may use 13.8 kilovolts (KV) electrical connections to receive power fromthe mobile source of electric power 102. The switch gear transport 112may comprise a plurality of electrical disconnect switches, fuses,transformers, and/or circuit protectors to protect the fracturingequipment. The switch gear transport 112 may transfer the electricityreceived from the mobile source of electricity 102 to the drive powertransports 104 and auxiliary power transports 106.

The auxiliary power transport 106 may comprise a transformer and acontrol system to control, monitor, and provide power to theelectrically connected fracturing equipment. In one embodiment, theauxiliary power transport 106 may receive the 13.8 KV electricalconnection and step down the voltage to 4.8 KV, which is provided toother fracturing equipment, such as the fracturing pump transport 108,the blender transport 110, sand storage and conveyor, hydrationequipment, chemical equipment, data van 114, lighting equipment, and anyadditional auxiliary equipment used for the fracturing operations. Theauxiliary power transport 106 may step down the voltage to 4.8 KV ratherthan other voltage levels, such as 600 V, in order to reduce cable sizefor the electrical connections and the amount of cabling used to connectthe mobile fracturing system 103. The control system may be configuredto connect to a control network system such that the auxiliary powertransport 106 may be monitored and/or controlled from a distantlocation, such as the data van 114 or some other type of control center.

The drive power transports 104 may be configured to monitor and controlone or more electrical motors located on the fracturing pump transports108 via a plurality of connections, such as electrical connections(e.g., copper wires), fiber optics, wireless, and/or combinationsthereof. The connections are omitted from FIG. 1 for clarity of thedrawing. The drive power transports 104 may be part of the controlnetwork system, where each of the drive power transports 104 compriseone or more variable frequency drives (VFDs) used to monitor and controlthe prime movers on the fracturing pump transports 108. The controlnetwork system may communicate with each of the drive power transports104 to monitor and/or control each of the VFDs. The VFDs may beconfigured to control the speed and torque of the prime movers byvarying the input frequency and voltage to the prime movers. Using FIG.1 as an example, each of the drive power transports 104 may beconfigured to drive a plurality of the fracturing pump transports 108.Other drive power transport to fracturing pump transport ratios may beused as desired. In one embodiment, the drive power transports 104 maycomprise air filters and blowers that intake ambient air to cool theVFDs. Other embodiments of the drive power transports 104 may use an airconditioning units and/or water cooling to regulate the temperature ofthe VFDs.

The fracturing pump transport 108 may receive the electric powerreceived from the drive power transport 104 to power a prime mover. Theprime mover converts electric power to mechanical power for driving oneor more pumps. In one embodiment, the prime mover may be a dual shaftelectric motor that drives two different pumps. The fracturing pumptransport 108 may be arranged such that one pump is coupled to oppositeends of the dual shaft electric motor and avoids coupling the pumps inseries. By avoiding coupling the pump in series, the fracturing pumptransport 108 may continue to operate when either one of the pumps failsor have been removed from the fracturing pump transport 108.Additionally, repairs to the pumps may be performed withoutdisconnecting the system manifolds that connect the fracturing pumptransport 108 to other fracturing equipment within the mobile fracturingsystem 103 and wellhead 101. Details regarding implementing thefracturing pump transport 108 are discussed in more detail in FIGS.7A-7B.

The blender transport 110 may receive the electric power fed through theauxiliary power transport 106 to power a plurality of electric blenders.A plurality of prime movers may drive one or more pumps that pump sourcefluid and blender additives (e.g., sand) into a blending tub, mix thesource fluid and blender additives together to form fracturing fluid,and discharge the fracturing fluid to the fracturing pump transport 108.In one embodiment, the electric blender may be a dual configurationblender that comprises electric motors for the rotating machinery thatare located on a single transport, which is described in more detail inU.S. Patent Application Publication No. 2012/0255734, filed Apr. 6, 2012by Todd Coli et al. and entitled “Mobile, Modular, Electrically PoweredSystem for use in Fracturing Underground Formations,” which is hereinincorporated by reference in its entirety. In another embodiment, aplurality of enclosed mixer hoppers may be used to supply the proppantsand additives into a plurality of blending tubs. The electric blenderthat comprises the enclosed mixer hoppers are discussed in more detailin FIGS. 9A and 9B.

The data van 114 may be part of a control network system, where the datavan 114 acts as a control center configured to monitor and provideoperating instructions in order remotely operate the blender transport110, the mobile source of electricity 102, and fracturing pump transport108 and/or other fracturing equipment within the mobile fracturingsystem 103. For example, the data van 114 may communicate via thecontrol network system with the VFDs located within the drive powertransports 104 that operate and monitor the health of the electricmotors used to drive the pumps on the fracturing pump transports 108. Inone embodiment, the data van 114 may communicate with the variety offracturing equipment using a control network system that has a ringtopology. A ring topology may reduce the amount of control cabling usedfor fracturing operations and increase the capacity and speed of datatransfers and communication. Details regarding implementing the controlnetwork system are discussed in more detail in FIG. 10.

Other fracturing equipment shown in FIG. 1, such as gas conditioningtransport, water tanks, chemical storage of chemical additives,hydration unit, sand conveyor, and sandbox storage are known by personsof ordinary skill in the art, and therefore are not discussed in furtherdetail. In one or more embodiments of the mobile fracturing system 103,one or more of the other fracturing equipment shown in FIG. 1 may beconfigured to receive power generated from the mobile source ofelectricity 102. Additionally, as shown in FIG. 1, one or moreembodiments of the mobile fracturing system 103 may not include the useof a missile that receives low-pressure fluid and releases high-pressurefluid towards the wellhead 101. The control network system for themobile fracturing system 103 may remotely synchronizes and/or slaves theelectric blender of the blender transport 110 with the electric motorsof the fracturing pump transports 108. Unlike a conventional dieselpowered blender, the electric blenders may perform rate changes to thepump rate change mounted on the fracturing pump transports 108. In otherwords, if the pumps within the fracturing pump transports 108 perform arate change increase, the electric blender within a blender transport110 may also automatically compensate its rate and ancillary equipment,such as the sand conveyor, to accommodate the rate change. Manualcommands from an operator may not be used to perform the rate change.

FIG. 2 is a schematic diagram an embodiment of a well site 200 thatincludes a mobile source of electricity 204 that comprises threetransports for the mobile fracturing system 202. The mobile fracturingsystem 202 may be substantially similar to mobile fracturing system 103,except that mobile fracturing system comprises an auxiliary gas turbinegenerator transport 206. The auxiliary gas turbine generator transport206 may be configured to provide power to ignite, start, or power on themobile source of electricity 204 and/or provide ancillary power wherepeak electric power demand exceeds the electric power output of a gasturbine generator transport. The auxiliary gas turbine generatortransport may comprise a smaller, gas turbine or diesel generator thatgenerates less power (e.g., provides about 1-8 MW of electric power)than the one used in the gas turbine generator transport. Additionallyor alternatively, the auxiliary gas turbine generator transport 206 mayprovide testing, standby, peaking, and/or other emergency backup powerfunctionality for the mobile fracturing system 202.

FIG. 2 illustrates that the mobile fracturing system 202 arranges andpositions the drive power transport 104 and the auxiliary powertransport 106 in an orientation that is about parallel to the switchgear transport 112 and the fracturing pump transports 108. Positioningthe drive power transport 104 and the auxiliary power transport 106 in aparallel orientation rather than about a perpendicular orientation asshown in FIG. 1 may be beneficial, for example reducing the foot printof the mobile fracturing system 202. Moreover, FIG. 2 also illustratesthat a fuel source 208, such as natural gas from a producing wellhead,may be located at the well site and be used by the mobile source ofelectricity 204 to generate electricity.

Although FIGS. 1 and 2 illustrate a specific configuration for a mobilefracturing system 103 at a well site 100, the disclosure is not limitedto that application and/or the specific embodiment illustrated in FIGS.1 and 2. For instance, embodiments of the present disclosure may includea plurality of wellheads 101, a plurality of blender transports 110, anda plurality of auxiliary power transports 106. Additionally, the mobilesource of electricity 102 is not limited for use in a fracturingoperation and may be applicable to power other types of equipment anddevices not typically used in a fracturing operation. The use anddiscussion of FIGS. 1 and 2 is only an example to facilitate ease ofdescription and explanation.

FIG. 3 is a schematic diagram an embodiment of a well site 300 thatincludes two wellheads 101 and two data vans 114. The two data vans 114may be part of the control network system that simultaneously monitorsand provides operating instructions to the two different wellheads 101.An additional blender transport 110 may be added to provide fracturingfluid to fracturing pump transports 108 used to fracture the subsurfacegeological structure underneath the second wellhead 101. Although FIG. 3illustrates that both wellheads 101 are located on the same well site300, other embodiments may have the wellheads 101 located at differentwell sites.

Mobile Source of Electricity

The mobile source of electricity may be part of the mobile fracturingsystem used at a well site as described in FIGS. 1-3. In other words,the mobile source of electricity may be configured to be transportableto different locations (e.g., different well sites) along with otherfracturing equipment (e.g., fracturing pump transports) that are part ofthe mobile fracturing system and may not be left behind after completingfracturing operations. The mobile source of electricity may include atleast two different transports that improve mobility of the dedicatedelectric power by simplifying and minimizing the operations for themobilization and de-mobilization process. For example, the mobile sourceof electricity may improve mobility by enabling a mobilization andde-mobilization time period of about 24 hours. The mobile source ofelectricity also incorporates a two transport footprint, where the sametwo transport system may be used for transportation and operation modes.Although FIGS. 4A-6 illustrate embodiments of implementing a mobilesource of electricity using two different transports, other embodimentsof the mobile source of electricity may mount the gas turbine generator,air inlet filter housing, gas turbine exhaust stack, and othercomponents shown in FIGS. 4A-6 on a different number of transports(e.g., all on one transport or more than two transports). To provideelectric power for fracturing operations at one or more locations (e.g.,well sites), the mobile source of electricity be designed to unitize andmobilize a gas-turbine and generator adapted to convert hydrocarbonfuel, such as natural gas, into electricity.

FIGS. 4A and 4B are schematic diagrams of an embodiment of the gasturbine generator transport 400. FIG. 4A illustrates a side-profile viewof the gas turbine generator transport 400 with a turbine enclosure 402that surrounds components within the gas turbine generator transport 400and includes cavities for the inlet plenum 404, exhaust collector 406,and an enclosure ventilation inlet 418. FIG. 4B illustrates aside-profile view of the gas turbine generator transport 400 thatdepicts the components within the turbine enclosure 402. As shown inFIG. 4B, the gas turbine generator transport 400 may comprise thefollowing equipment: (1) an inlet plenum 404; (2) a gas turbine 407(e.g., General Electric (GE) 2500); (3) an exhaust collector 406; (4) agenerator 408; (5) a generator breaker 410; and (6) a control system412. Other components not shown in FIG. 4B, but which may also belocated on the gas turbine generator transport 400 include a turbinelube oil system, a fire suppression system, and a generator lube oilsystem.

The gas turbine generator transport 400 includes the gas turbine 407 togenerate mechanical energy (i.e., rotation of a shaft) from ahydrocarbon fuel source, such as natural gas, liquefied natural gas,condensate, and/or other liquid fuels. As shown in FIG. 4B, the gasturbine shaft is connected to the generator 408 such that the generator408 converts the supplied mechanical energy from the rotation of theshaft to produce electric power. The gas turbine 407 may be a gasturbine, such as the GE LM2500 family of gas turbines, the Pratt andWhitney FT8 gas turbines, or any other gas turbine that generates enoughmechanical power for a generator 408 to power fracturing operations atone or more well sites. The generator 408 may be a Brush BDAX 62-170ERgenerator or any other generator configured to generate electric powerfor fracturing operations at one or more well sites. For example, thegas turbine 407 and generator 408 combination within a gas turbinegenerator transport 400 may generate electric power from a range of atleast about 15 megawatt (MW) to about 35 MW. Other types of gas-turbinegenerators with power ranges greater than about 35 MW or less than about15 MW may also be used depending on the amount of power needed at thewell sites. In one embodiment, to increase mobility of the gas turbinegenerator transport 400, the gas turbine 407 may be configured to fitwithin a dimension of about 14.5 feet long and about four feet indiameter and/or the generator 408 may be configured to fit within adimension of about 18 feet long and about 7 feet wide.

The generator 408 may be housed within the turbine enclosure 402 thatincludes air ventilation fans internal to the generator 408 that drawsair into the air inlet located on the front and/or back of the generator408 and discharges air out on the sides via the air outlets 414. Otherembodiments may have the air outlets positioned on different locationsof the enclosure for the generator 408. In one embodiment, the air inletmay be inlet louvres and the air outlets may be outlet louvres thatprotect the generator from the weather elements. A separate generatorventilation stack unit may be mounted on the top of the gas turbinegenerator transport 400.

The turbine enclosure 402 may also comprise gas turbine inlet filter(s)configured to provide ventilation air and combustion air via one or moreinlet plenums 404 to the gas turbine 407. Additionally, enclosureventilation inlets 418 may be added to increase the amount ofventilation air. The ventilation air may be air used to cool the gasturbine 407 and ventilate the gas turbine enclosure 402. The combustionair may be the air that is supplied to the gas turbine 407 to aid in theproduction of the mechanical energy. The inlet plenum 404 may beconfigured to collect the intake air from the gas turbine inlet filterand supply the intake air to the gas turbine. The exhaust collector 406may be configured to collect the air exhaust from the gas turbine andsupply the exhaust air to the gas turbine exhaust stack.

To improve mobility of the gas turbine generator transport 400, the airinlet filter housing and the gas turbine exhaust stack are configured tobe connected from at least one of the sides of the turbine enclosure402, as opposed to connecting both the air inlet filter housing and thegas turbine exhaust stack on the top of the turbine enclosure 402 orconnecting the air inlet filter housing at one end of the gas turbinegenerator transport 400 and connecting the exhaust collector from theside of the turbine enclosure 402. The air inlet filter housing and gasturbine exhaust stack from the inlet and exhaust transport may connectwith the turbine enclosure 402 using one or more expansion connectionsthat extend from one or both of the transports, located at the sides ofthe turbine enclosure 402. Any form of connection may be used thatprovides coupling between the turbine enclosure 402 and the air inletfilter housing and gas turbine exhaust stack without using a crane,forklift, and/or any other external mechanical means to connect theexpansion connections in place and/or to connect the air inlet filterhousing and gas turbine exhaust stack to the side of the turbineenclosure 402. The expansion connections may comprise a duct and/or anexpansion joint to connect the air inlet filter housing and gas turbineexhaust stack to the turbine enclosure 402. Additionally, the routing ofthe air inlet filter housing and gas turbine exhaust stack via the sidesof the turbine enclosure 402 may provide a complete aerodynamic modelingwhere the inlet air flow and the exhaust air flow are used to achievethe gas turbine nameplate output rating. The inlet and exhaust transportis discussed in more detail later in FIGS. 5A and 5B.

To improve mobility over a variety of roadways, the gas turbinegenerator transport 400 in FIGS. 4A and 4B may have a maximum height ofabout 13 feet and 6 inches, a maximum width of about 8 feet and 6inches, and a maximum length of about 66 feet. Further, the gas turbinegenerator transport 400 may comprise at least three axles used tosupport and distribute the weight on the gas turbine generator transport400. Other embodiments of the gas turbine generator transport 400 may betransports that exceed three axles depending on the total transportweight. The dimensions and the number of axles may be adjusted to allowfor the transport over roadways that typically mandate certain height,length, and weight restrictions.

In one embodiment, the gas turbine 407 and generator 408 may be mountedto an engineered transport frame 416, a sub-base, sub-skid, or any othersub-structure used to support the mounting of gas turbine 407 andgenerator 408. The single engineered transport frame may be used toalign the connections between the gas turbine 407, the generator 408,the inlet plenum 404 and the exhaust collector 406 and/or lower the gasturbine and generator by configuring for a flush mount to the singleengineered transport frame 416. The single engineered transport frame416 may allow for easier alignment and connection of the gas turbine 407and generator 408 compared to using separate sub-base for the gasturbine 407 and generator 408. Other embodiments of the gas turbinegenerator transport 400 may use a plurality of sub-bases, for example,mounting the gas turbine 407 on one sub-base and mounting the generator408 on another sub-base.

FIG. 4B illustrates that the generator breaker 410 and control systems412 may be located on the gas turbine generator transport 400. Thegenerator breaker 410 may comprise one or more circuit breakers that areconfigured to protect the generator 408 from current and/or voltagefault conditions. The generator breaker 410 may be a medium voltage (MV)circuit breaker switchboard. In one embodiment, the generator breakermay be about three panels, two for the generator and one for a feederthat protect relays on the circuit breaker. In one embodiment, thegenerator breaker 410 may be vacuum circuit breaker. The control system412 may be configured to control, monitor, regulate, and adjust thepower output of the gas turbine 407 and generator 408. For example, thecontrol system 412 may monitor and balance the load produced by thefracturing operations by generating enough electric power to match theload demands. The control system 412 may also be configured tosynchronize and communicate with a control network system that allows adata van or other computing systems located in a remote location (e.g.,off the well site) to control, monitor, regulate, and adjust poweroutput of the generator 408. Although FIG. 4B illustrates that thegenerator breaker 410 and/or control system 412 may be mounted on thegas turbine generator transport 400, other embodiments of the mobilesource of electricity may mount the generator breaker 410 and/or controlsystem 412 in other locations (e.g. switch gear transport).

Other equipment that may also be located on the gas turbine generatortransport 400, but are not shown in FIGS. 4A and 4B include the turbinelube oil system, gas fuel valves, generator lube oil system, and firesuppression system. The lube oil systems or consoles, which generallyrefer to both the turbine lube oil system and generator lube oil systemwithin this disclosure, may be configured to provide a generator andturbine lube oil filtering and cooling systems. In one embodiment, theturbine lube oil console area of the transport may also contain the firesuppression system, which may comprise sprinklers, water mist, cleanagent, foam sprinkler, carbon dioxide, and/or other equipment used tosuppress a fire or provide fire protection for the gas turbine 407. Themounting of the turbine lube oil consoles and the fire suppressionsystem onto the gas turbine generator transport 400 reduces thistransport's footprint by eliminating the need for an auxiliary transportand connections for the turbine and generator lube oil, filtering,cooling systems and the fire suppression system to the gas turbinegenerator transport. The turbine and generator lube oil systems may bemounted on a skid that is located underneath the generator 408 or anyother location on the gas turbine generator transport 400.

FIGS. 5A and 5B are schematic diagrams of embodiments of an inlet andexhaust transport 500. Specifically, FIG. 5A depicts the inlet andexhaust transport 500 while in transportation mode and FIG. 5B depictsthe inlet and exhaust transport 500 while in operational mode. As shownin FIGS. 5A and 5B, the inlet and exhaust transports 500 include an airinlet filter housing 502 and a gas turbine exhaust stack 504. Althoughnot shown in FIGS. 5A and 5B, one or more gas turbine inlet filters andventilation fans may be located within or housed in the air inlet filterhousing 302.

FIGS. 5A and 5B illustrate that the air inlet filter housing 502 may bemounted on the inlet and exhaust transport 500 at a fixed location.Other embodiments of the inlet and exhaust transport 500 may mount theair inlet filter housing 502 with a configuration such that the airinlet filter housing 502 may slide in one or more directions whentransitioning between operational mode and transportation mode. Forexample, as shown in FIG. 5C, the air inlet filter housing 502 may slideout for operational mode and slide back for transport mode. Sliding theair inlet filter housing 502 may be used to align the air inlet filterhousing 502 with the inlet plenum of the gas turbine enclosure mountedon the gas turbine generator transport. In another embodiment, the airinlet filter housing 502 may be mounted on a turntable with the abilityto engage the inlet plenum of the gas turbine enclosure mounted on thegas turbine generator transport. The air inlet filter housing 502 maycomprise a plurality of silencers that reduce noise. The differentembodiments for mounting the air inlet filter housing 502 may depend onthe amount of clean air and the air flow dynamics needed to supply thegas turbine for combustion.

The gas turbine exhaust stack 504 may comprise the gas turbine exhaust508, an exhaust extension 506 configured for noise control, and anexhaust end connector 510. The exhaust extension 506 may comprise aplurality of silencers that reduce noise from the inlet and exhausttransport 500. As shown in FIG. 5A, the gas turbine exhaust stack 504may be mounted to initially lie on its side during transportation mode.In operational mode, the gas turbine exhaust stack 504 may be rotated upwithout using external mechanical means such that the gas turbineexhaust stack 504 is mounted to the inlet and exhaust transport 500 onits base and in the upright position. In operational mode, the gasturbine exhaust stack 504 may be positioned using hydraulics,pneumatics, and/or electric motors such that it aligns and connects withthe exhaust end connector 510 and exhaust collector of the gas turbineenclosure shown in FIGS. 4A and 4B.

The exhaust end connector 510 may be adjusted to accommodate and alignthe gas turbine exhaust stack 504 with the exhaust collector of the gasturbine enclosure. In operational mode, the exhaust end connector 510may move forward in a side direction, which is in the direction towardthe gas turbine enclosure. The exhaust end connector 510 may movebackward in the side direction, which is in the direction away from thegas turbine enclosure, when transitioning to the transportation mode.Other embodiments of the gas turbine exhaust stack 504 may have the gasturbine exhaust 508 and the exhaust end connector 510 connected as asingle component such that the exhaust end connector 510 and the gasturbine exhaust stack 504 are rotated together when transitioningbetween the transportation and operational modes.

In another embodiment, during transport, the gas turbine exhaust stack504 may be sectioned into a first section and a second section. Forexample, the first section may correspond to the gas turbine exhaust 508and the second section may correspond to the exhaust extension 506. Thefirst section of the gas turbine exhaust stack 508 may be in the uprightposition and the second section of the gas turbine exhaust stack 506 maybe mounted adjacent to the first section of the gas turbine exhaust fortransport. The first section and the second section may be hingedtogether such that the second section may be rotated up to stack on topof the first section for operation. In another embodiment, the gasturbine exhaust stack 504 may be configured such that the entire gasturbine exhaust stack 504 may be lowered or raised while mounted on theinlet and exhaust transport 500.

Typically, the air inlet filter housing 502 and gas turbine exhauststack 504 may be transported on separate transports and subsequentlycrane lifted onto the top of gas turbine enclosure and mounted on thegas turbine generator transport during operation mode. The separatetransports to carry the air inlet filter housing 502 and gas turbineexhaust stack 504 may not be used during operational mode. However, byadapting the air inlet filter housing 502 and gas turbine exhaust stack504 to be mounted on a single transport and to connect to at least oneof the sides of the gas turbine enclosure mounted on the gas turbinegenerator transport, the inlet and exhaust transport may be positionedalongside the gas turbine generator transport and subsequently connectthe air inlet and exhaust plenums for operations. The result is having arelatively quick rig-up and/or rig-down that eliminates the use of heavylift cranes, forklifts, and/or any other external mechanical means atthe operational site.

FIG. 6 is a schematic diagram of an embodiment of the two transportmobile electric power source 600 when in operational mode. FIG. 6illustrates a top-down-view of the coupling between the inlet andexhaust transport 500 and the gas turbine transport 400 duringoperational mode. The exhaust expansion connection 602 may move andconnect (e.g., using hydraulics) to the exhaust end connector 510without using external mechanical means in order to connect the gasturbine exhaust stack of the inlet and exhaust transport with theexhaust collector of the gas turbine generator transport. The inletexpansion connections 604 may move and connect the air inlet filterhousing of the inlet and exhaust transport and the inlet plenum of thegas turbine generator transport. The two transports 400 and 500 may beparked at a predetermined orientation and distance such that the exhaustexpansion connection 602 and inlet expansion connections 604 are able toconnect the two transports 400 and 500.

In one embodiment, to adjust the positioning, alignment, and distance inorder to connect the two transports 400 and 500, each of the transports400 and 500 may include a hydraulic walking system. For example, thehydraulic walking system may move and align transport 500 into aposition without attaching the two transports 400 and 500 totransportation vehicles (e.g., a tractor or other type of motorvehicle). Using FIGS. 4 and 5 as an example, the hydraulic walkingsystem may comprise a plurality of outriggers and/or support feet 412used to move transport 400 and/or transport 500 back and forth and/orsideways. At each outrigger and/or support feet 412, the hydraulicwalking system may comprise a first hydraulic cylinder that lifts thetransport and a second hydraulic cylinder that moves the transport inthe designated orientation or direction. A hydraulic walking system onthe transport increases mobility by reducing the precision needed whenparking the two transports next to each other.

FIG. 11 is a flow chart of an embodiment of a method 1100 to provide amobile source of electricity for fracturing operations. Method 1100 maystart at block 1102 by transporting a mobile source of electricity withother fracturing equipment to a well site that comprises a non-producingwell. Method 1100 may then move to block 1104 and convert the mobilesource of electricity from transportation mode to operational mode. Thesame transports may be used during the conversation from transportationmode to operational mode. In other words, transports are not addedand/or removed when setting up the mobile source of electricity foroperational mode. Additionally, method 1100 be performed without the useof a forklift, crane, and/or other external mechanical means totransition the mobile source of electricity into operational mode. Theconversion process for a two transport trailer is described in moredetail in FIGS. 4A-6.

Method 1100 may then move to block 1106 and generate electricity usingthe mobile source of electricity to power fracturing operations at oneor more well sites. In one embodiment, method 1100 may generateelectricity by converting hydrocarbon fuel into electricity using a gasturbine generator. Method 1100 may then move to block 1108 and convertthe mobile source of electricity from operational mode to transportationmode. Similar to block 1104, the conversion process for block 1108 mayuse the same transports without using a forklift, crane, and/or otherexternal mechanical means to transition the mobile source of electricityback to transportation mode. Method 1100 may then move to block 1110 toremove the mobile source of electricity along with other fracturingequipment from the well site once fracturing operations are completed.

Fracturing Pump Transport

FIGS. 7A and 7B are schematic diagrams of embodiments of a fracturingpump transport 700 powered by the mobile source of electricity asdescribed in FIGS. 4A-6. The fracturing pump transport 700 may include aprime mover 704 powering two separate pumps 702A and 702B. By combininga single prime mover 704 attached to two separate pumps 702A and 702B ona transport, a fracturing operation may reduce the amount of pumptransports, prime movers, variable frequency drives (VFD's), groundiron, suction hoses, and/or manifold transports. Although FIGS. 7A and7B illustrates that the fracturing pump transport 700 supports a singleprime mover 704 power two separate pumps 702A and 702B, otherembodiments of the fracturing pump transport 700 may include a pluralityof prime movers 704 that each power the pumps 702A and 702B.

A “lay-down” trailer 710 design may provide mobility, improved safety,and enhanced ergonomics for crew members to perform routine maintenanceand operations of the pumps as the “lay-down” arrangement positions thepumps lower to the ground as the main trailer beams are resting on theground for operational mode. As shown in FIGS. 7A and 7B, the “lay-down”trailer 710 has an upper section above the trailer axles that could holdor have mounted the fracturing pump trailer power and control systems708. The fracturing pump trailer power and control system 708 maycomprise one or more electric drives, transformers, controls (e.g., aprogrammable logic controller (PLC) located on the fracturing pumptransport 700), and cables for connection to the drive power trailersand/or a separate electric pumper system. The electric drives mayprovide control, monitoring, and reliability functionality, such aspreventing damage to a grounded or shorted prime mover 704 and/orpreventing overheating of components (e.g., semiconductor chips) withinthe electric drives. The lower section, which may be positioned lowerthan the trailer axles, may hold or have mounted the prime mover 704 andthe pumps 702A and 702B attached on opposite sides of each other.

In one embodiment, the prime mover 704 may be a dual shaft electricmotor that has a motor shaft that protrudes on opposite sides of theelectric motor. The dual shaft electric motor may be any desired type ofalternating current (AC) or direct current (DC) motor. In oneembodiment, the dual shaft electric motor may be an induction motor andin another embodiment the dual shaft electric motor may be a permanentmagnet motor. Other embodiments of the prime mover 704 may include otherelectric motors that are configured to provide about 5,000 HP or more.For example, the dual shaft electric motor may deliver motor power in arange from about 1,500 HP to about 10,000 HP. Specific to someembodiments, the dual shaft electric motor may be about a 5,000 HP ratedelectric motor or about a 10,000 HP electric motor. The prime mover 704may be driven by at least one variable frequency drive that is rated toa maximum of about 5,000 HP and may receive electric power generatedfrom the mobile source of electric power.

As shown in FIGS. 7A and 7B, one side of the prime mover 704 drives onepump 702A and the opposite side of the prime mover 704 drives a secondpump 702B. The pumps 702A and 702B are not configured in a seriesconfiguration in relation to the prime mover 704. In other words, theprime mover 704 independently drives each pump 702A and 702B such thatif one pump fails, it can be disconnected and the other pump cancontinue to operate. The prime mover 704, which could be a dual shaftelectric motor, eliminates the use of diesel engines and transmissions.Moreover, using a dual shaft electric motor on a transport may preventdissonance or feedback when transferring power to the pumps. In oneembodiment, the prime mover 704 may be configured to deliver at leastabout 5,000 HP distributed between the two pumps 702A and 702B. Forinstance, prime mover 704, which may be a dual shaft electric motor, mayprovide about 2,500 HP to one of the pumps 702A and about 2,500 HP tothe other pump 702B in order to deliver a total of about 5,000 HP. Otherembodiments may have the prime mover 704 deliver less than 5,000 HP ormore than 5,000 HP. For example, the prime mover 704 may deliver a totalof about 3,000 HP by delivering about 1,500 HP to one of the pumps andabout 1,500 HP to the other pump. Another example may have the primemover 704 deliver a total of about 10,000 HP by delivering about 5,000HP to one of the pumps 702A and about 5,000 HP to another pump 702B.Specifically, in one or more embodiments, the prime mover 704 mayoperate at HP ratings of about 3,000 HP, 3,500 HP, 4,000 HP, 4,500 HP,5,000 HP, 5,200 HP, 5,400 HP, 6,000 HP, 7,000 HP, 8,000 HP, 9,000 HP,and/or 10,000 HP.

The fracturing pump transport 700 may reduce the footprint of fracturingequipment on a well-site by placing two pumps 702A and 702B on a singletransport. Larger pumps may be coupled to a dual shaft electric motorthat operates with larger horse power to produce additional equipmentfootprint reductions. In one embodiment, each of the pumps 702A and 702Bmay be quintiplex pumps located on a single transport. Other embodimentsmay include other types of plunger style pumps, such as triplex pumps.The pumps 702A and 702B may each operate from a range of about 1,500 HPto about 5,000 HP. Specifically, in one or more embodiments, each of thepumps 702A and 702B may operate at HP ratings of about 1,500 HP, 1,750HP, 2,000 HP, 2,250 HP, 2,500 HP, 2,600 HP, 2,700 HP, 3,000 HP, 3,500HP, 4,000 HP, 4,500 HP, and/or 5,000 HP. The pumps 702A and 702B may notbe configured in a series configuration where the prime mover 704 drivesa first pump 702A and the first pump 702B subsequently drives a secondpump 702B.

FIG. 7A also illustrates that each pump 702A and 702B, which may also begenerally referred to in this disclosure as pump 702, is mounted on thefracturing pump transport 700 with the same orientation. In particular,each pump 702 is mounted such that the fluid end assembly 716 for eachpump 702 is facing the same side of the fracturing pump transport 700.Additionally, in FIG. 7A, the power end assembly 718 for each pump 702is facing the same side of the fracturing pump transport 700. In otherwords, for a given pump 702 (e.g., pump 702A), the fluid end assembly716 and power end assembly 718 are located on opposite sides of thefracturing pump transport 700. As shown in FIG. 7A, both the fluid endassembly 716 and power end assembly 718 of a pump 702 may face sides ofthe fracturing pump transport 700 that are about orthogonal orperpendicular to the front end 720 and back end 722 of the fracturingpump transport 700. Having the fluid end side 716 of each pump 702 facethe same side of the fracturing pump transport 700 may be beneficial bysimplifying and reducing the amount of plumbing used to route both thelow pressure fluid line and high pressure fluid line into and out of thefracturing pump transport 700. For example, if pump 702A's and 702B'sfluid end assembly 716 are facing opposite sides of the fracturing pumptransport 700, the fracturing pump transport 700 may include plumbingthat routes both the low pressure fluid lines and high pressure fluidlines on both sides of the fracturing pump transport 700. Alternatively,if pump 702A's and 702B's fluid end assembly 716 are facing the sameside of the fracturing pump transport 700, at least a majority of theplumbing that routes both the low pressure fluid lines and high pressurefluid lines could be located on one side of the fracturing pumptransport 700.

In one embodiment, to mount both pumps 702 where the fluid endassemblies 716 are facing the same side of the fracturing pump transport700, one of the pumps 702 (e.g., pump 702B) may be configured with aright-side pinion while the other pump 702 (e.g., pump 702A) isconfigured with a pinion located on the opposite side of the pump 702,which can be referred to as a left-side pinion. In particular, a pump702 with a right-side pinion may be designated to mount to a specificside of the prime mover 704, such as the side of the prime mover 704facing the back end 722 (e.g., the end with trailer axles), and the pump702 with a left-side pinion may be designated to mount on the other sideof the prime mover 704, such as the side of the prime mover 704 facingthe front end 720 (e.g., trailer hitch). Because the pumps 702 arelocated on opposite sides of the prime mover 704, placing pinions ondifferent sides of the pumps 702 allows the fluid end assembly 716 foreach pump 702 to face the same side of the fracturing pump transport700.

In another embodiment, the fracturing pump transport 700 may include oneor more pumps 702 configured with a dual pinion 724. A pump 702 with thedual pinion configuration would include both a left-side pinion and aright-side pinion. FIG. 7B illustrates that each pump 702A and 702B hasa dual pinion 724, where the two pinion ends are located on oppositesides of each other. Having pumps 702 configured with a dual pinion 724provides additional flexibility compared to pumps 702 with either aright-side pinion or a left-side pinion. Specifically, a pump 702 with adual pinion 724 may be able to mount on either side of the prime mover704 while having the fluid end assembly 716 for each pump 702 face thesame side of the fracturing pump transport 700.

Another advantage of having the fluid end assemblies 716 face the sameside of the fracturing pump transport 700 is to avoid damaging the pump702 at different loads and/or requiring mounting of a custom fracturingpump. In embodiments where the fluid end assemblies 716 are facingopposite directions, the pinions for pumps 702A and 702B may be rotatingin opposite directions when driven by the prime mover 704. A pinion,whether a right-pinion, left-pinion, or a dual pinion 724, may belocated within the power end assembly 718 and includes a pinion shaftand one or more pinion gears configured to generate rotational movementof the power end assembly 718. The rotational movement may generatetorque that moves the plungers in the fluid end assembly 716 used topump and pressurize fracturing fluid. To produce torque, typically, apinion gear may interface with a bull gear that drives a crankshaft,which in turn moves the fluid end plungers. The pinion gear and the bullgear are commonly helical gears configured to engage with each other byrotating in a specified direction. If the pinion shaft, pinion gear, andbull gear are rotated in a direction opposite to the designed direction,the pinion gear may turn the bull gear until the pinion gear generatesenough torque to break the bull gear and damage the pump 702. To avoiddamaging the pumps 702, one of the pumps 702 would need to be customizedto provide torque when the pinion rotates in a direction opposite ofconventional fracturing pumps. Including a customized fracturing pump onthe fracturing pump transport 700 could not only lead to an increase inmanufacturing cost, but also decrease operational and maintenanceflexibility by requiring pumps 702A and 702B to be mounted on designatedsides of the prime mover 704.

The prime mover 704 and each of the pumps 702A and 702B may be mountedon sub-assemblies configured to be isolated and allow for individualremoval from the fracturing pump transport. In other words, the primemover 704 and each of the pumps 702A and 702B can be removed fromservice and replaced without shutting down or compromising otherportions of the fracturing system. The prime mover 704 and pumps 702Aand 702B may be connected to each other via couplings that aredisconnected when removed from the fracturing pump transport 700. If theprime mover 704 needs to be replaced or removed for repair, the primemover sub-assembly may be detached from the fracturing pump transport700 without removing the two pumps 702A and 702B from the fracturingpump transport. For example, pump 702A can be isolated from thefracturing pump transport 700, removed and replaced by a new pump 702A.If the prime mover 704 and/or the pumps 702A and 702B requires service,an operator can isolate the different components from the fluid lines,and unplug, un-pin, and remove the prime mover 704 and/or the pumps 702Aand 702B from the fracturing pump transport. Furthermore, each pump 702Aand 702B sub-assembly may be detached and removed from the fracturingpump transport 700 without removal of the other pump and/or the primemover 704. As such, the fracturing pump transport 700 may not need to bedisconnected from the manifold system and driven out of the location.Instead, replacement prime mover 704 and/or the pumps 702A and 702B maybe placed backed into the line and reconnected to the fracturing pumptransport 700.

To implement the independent removal of the sub-assemblies, the twopumps 702A and 702B may be coupled to the prime mover 704 using a driveline assembly 706 that is adapted to provide remote operation thatengages and/or disengages one or both pumps 702A and 702B from the primemover 704. The drive line assembly 706 may comprise one or morecouplings and one or more drive shafts. For example, the drive lineassembly 706 may comprise a fixed coupling that connects to one of thepumps 702A or 702B, a keyed shaft 712, and an engagement coupling (e.g.,spline-tooth coupling 714). The keyed shaft 712 may interconnect thefixed coupling (e.g., a flex coupling or universal joint-based coupling)to a spline-tooth coupling 714 that attaches to the prime mover 704. Thefixed coupling may directly connect the keyed shaft 712 to the pinion ofthe pump or indirectly connect the keyed shaft 712 to the pinion of thepump using a pump drive shaft. To engage and/or disengage one or bothpumps 702A and 702B from the prime mover 704, the spline-tooth coupling714 may include a splined sliding sleeve coupling and a motor couplingthat provides motor shaft alignment with the keyed shaft 712. Hydraulicfluid and/or mechanical power may be used to adjust the splined slidingsleeve coupling to engage and/or disengage the pumps 702A and 702B fromthe prime mover 704. Other embodiments of couplings that may be used toengage and/or disengage the keyed shaft 712 from the prime mover 704 mayinclude torque tubes, air clutches, electro-magnetic clutches, hydraulicclutches, and/or other clutches and disconnects that have manual and/orremote operated disconnect devices.

FIG. 13 is a schematic diagram of an embodiment of a fracturing pumptransport 1300 configured to remotely engage and/or disengage one ormore pumps 702 from the prime mover 704. Although FIG. 13 illustratesthat the prime mover 704 is a dual-shaft electric motor, otherembodiments of the fracturing pump transport 1300 may use other types ofelectric motors, such an electric motor that has only one shaftextending outward. As shown in FIG. 13, the fracturing pump transport1300 may comprise an engagement panel 1302 and a monitoring station1304, such as a human monitoring interface (HMI) station. The engagementpanel 1302 may include a control system that adjusts an engagementcoupling to transition between an engaged and a disengaged position. Inone embodiment, the engagement panel 1302 may include levers or switchesthat an operator may manually operate to engage or disengage the keyedshaft 712 from the motor shaft using the engagement coupling.Additionally or alternatively, the engagement panel 1302 may includeelectronic controllers that receive instructions from remote locations,such as a monitoring station 1304, another location at the well site(e.g., data van), and/or off-site to engage and/or disengage the pumps702 from the prime mover 704. In response to receiving a remote command,the engagement panel 1302 may trigger the engagement and/ordisengagement of one or more of the pumps from the prime mover 704. Forinstance, if pump 702A was disengaged and pump 702B was engaged, inresponse to receiving the remote command, the engagement panel 1302 maytrigger the engagement of pump 702A and disengagement of pump 702B. Theremote command may also produce a result where both pumps 702 aredisengaged or engaged with the prime mover.

The engagement panel 1302 may vary its mounting location on thefracturing pump transport 1300 and the control mechanism used to engageand/or disengage the pumps 702 from the prime mover 704. Although FIG.13 illustrates the engagement panel 1302 is located at the front end ofthe fracturing pump transport 1300, other embodiments could have theengagement panel 1302 located at other locations, such as being part ofthe trailer power and control systems 708 and/or closer in proximity tothe trailer power and control systems 708. The control mechanismimplemented by the engagement panel 1302 may be based on the type ofengagement coupling used to engage or disengage the pumps 702 and primemover 704. For example, the engagement panel 1302 may be a hydrauliccontrol bank, which is discussed in more detail in FIGS. 15A and 15Bthat include hydraulic controllers (e.g., hydraulic and electroniccontrol valves) that manage hydraulic fluid pressure when the engagementcoupling is a splined tooth coupling.

The monitoring station 1304, which may be part of the trailer power andcontrol systems 708, may include hardware and/or software that allow anoperator to manage and control (e.g., provide instructions) theengagement panel 1302 to engage and/or disengage the pumps 702 from theprime mover 704. For example, the monitoring station 1304 may beconfigured with a safety control system that prevents the execution ofengagement and/or disengagement instructions when the prime mover and/orpumps are operational. In one embodiment, the monitoring station 1304may also include network components for receiving remote engagement ordisengagement instructions by connecting to a control network systemthat communicates with other fracturing equipment and/or controlsystems. The control network system is described in more detail in FIG.10.

The fracturing pump transport 1300 may also include proximity sensors(not shown in FIG. 13) used to determine whether the engagement couplingis in an engagement or disengagement position when performing remotemonitoring at the monitoring station 1304, another location at the wellsite (e.g., data van), and/or off-site. In one embodiment, the proximitysensors may be coupled to the engagement coupling and/or located inclose proximity to the engagement coupling to determine whether thepumps 702 are engaged and/or disengaged with the prime mover 704.Information obtained from the proximity sensors may also be useful inallowing the monitoring station 1304 and/or other control systems thatare part of the control network system (e.g., data van) to determine thenumber of operating pumps (e.g., none, one, or two) for fracturing pumptransport 1300. An operator and/or control system may use the number ofpumps to accurately measure the fluid pumping rate during operations.

FIGS. 14A and 14B are schematic diagrams of an embodiment of a driveline assembly 1400 used to remotely engage and/or disengage a pump froma prime mover. FIG. 14A illustrates that the engagement coupling 1410 isin an engagement position while FIG. 14B illustrates that the engagementcoupling 1410 is in a disengagement position. When manual and/or remoteinstructions are sent to move the engagement coupling 1410 into anengaged position, the engagement coupling 1410 may translate therotational movement from the motor shaft 1408 of the prime mover to thekeyed shaft (e.g., a driveline shaft or pump pinion). In a disengagedposition, the engagement coupling 1410 disengages the keyed shaft fromthe motor shaft 1408 of the prime mover such that the rotationalmovement is not translated to the keyed shaft even though the motorshaft 1408 continues to rotate. For FIGS. 14A and 14B, the keyed shaftwould be located underneath the shaft cover 1406 used to mount theproximity sensors 1404A and 1404B.

FIGS. 14A and 14B also illustrate that the engagement coupling 1410includes a spline-tooth coupling with a sleeve that moves back in forthusing hydraulic cylinders 1402 (e.g., hydraulic rams). When thehydraulic cylinders 1402 move the sleeve in a designated direction(e.g., in the direction of the pump) the spline-tooth coupling mayengage the keyed shaft and transfer rotational movement from the motorshaft 1408 to the keyed shaft. When the hydraulic cylinders 1402 movethe sleeve an opposite direction (e.g., in the direction of the primemover), the spline-tooth coupling may disengage the keyed shaft andisolate the rotational movement the motor shaft 1408 generates from thekeyed shaft. Other embodiments, may use mechanical power instead ofhydraulic power to move the sleeves of the spline-tooth coupling. Asshown in FIGS. 14A and 14B, the motor shaft 1408 may refer to one end ofthe dual shaft that protrudes out of the prime mover. Other embodimentscould have the motor shaft 1408 be a drive line shaft that is coupled toone end of the dual shaft of the prime mover. In other words, theengagement coupling 1410 may directly or indirectly connect the keyedshaft engagement coupling 1410 to a prime mover.

The drive line assembly 1400 may also include one or more proximitysensors 1404A and 1404B to determine the position of the engagementcoupling 1410, and one or more fixed couplings 1412 used to directly orindirectly couple the keyed shaft with a pump pinion. In FIG. 14A, theproximity sensor 1404A may detect when the engagement coupling 1410 isin an engagement position, and in FIG. 14B, the proximity sensor 1404Bmay detect when the engagement coupling 1410 has moved to adisengagement position. FIGS. 14A and 14B also depict fixed couplings1412 that couples the keyed shaft to a pump pinion. The drive lineassembly 1400 may vary the number of fixed couplings 1412 andintermediate drive shafts based on space availability, misalignmenttolerances, and whether vibrations from the pump need to be deflected toavoid affecting the operation of the prime mover. Additionally, in oneor more embodiments, the pump's pinion may move or walk slightly axially(e.g., 1/16ths of an inch). Having fixed couplings 1412 and intermediatedrive shafts may allow the pump's pinion shaft to move or walk slightlywithout damaging the motor shaft and/or bearings of the prime mover.Examples of fixed couplings 1412 may include, but are not limited to,flex couplings and/or universal joint-based coupling.

Although FIGS. 14A and 14B illustrate a specific embodiment of a driveline assembly 1400, the disclosure is not limited to the specificembodiment illustrated in FIGS. 14A and 14B. For instance, engagementcoupling 1410 may be implemented using other types of coupling, such astorque tubes, air clutches, electro-magnetic clutches, hydraulicclutches. The type of engagement coupling 1401 may then determine whatpowers the engagement and/or disengagement operation, such as hydraulic,mechanical, and/or electric power. Additionally, the engagement coupling1410 may be configured to statically and/or dynamically engage and/ordisengage the keyed shaft from the motor shaft 1408. In a staticengagement and/or disengagement, the pumps and/or prime mover may not beoperational when engagement or disengagement occurs. For instance, themotor shaft 1408 is not rotating when performing static engagementand/or disengagement. In a dynamic engagement and/or disengagement, thepumps, prime mover and/or motor shaft 1408 are rotating when engagementand/or disengagement occurs. For example, rather than using aspline-tooth coupling, the drive line assembly 1400 may use an airclutch to perform dynamic engagement or disengagement. The use anddiscussion of FIGS. 14A and 14B is only an example to facilitate ease ofdescription and explanation.

FIG. 15A is a schematic diagram of an embodiment of an engagement panel1500 configured to cause remote engagement and/or disengagement of oneor more pumps with a prime mover, and FIG. 15B is a schematic diagram ofan embodiment of a hydraulic control bank 1502 located within anengagement panel 1500. FIG. 15A illustrates that the engagement panel1500 includes a hydraulic control bank 1502 with one or more hydrauliclevers 1504 that operators may manually operate to trigger engagementand/or disengagement of one or more pumps from a prime mover. As shownin FIG. 15B, adjusting the hydraulic levers 1504 may activate hydrauliccontrol valves 1506 that adjust hydraulic fluid pressures to move anengagement coupling, such as a spline-tooth coupling, to an engagementand/or disengagement position. The hydraulic control bank 1502 may alsoinclude electronic control valves 1508 that adjust hydraulic fluidpressures based on instructions received from a remote location, such asa monitoring station, another location at the well site (e.g., datavan), and/or off-site. In one embodiment, the electronic control valves1508 may include one or more electronic solenoids that adjust thehydraulic fluid pressures to engage and/or disengage one or more pumpsfrom the prime mover. Additionally or alternatively, the engagementpanel 1500 may also be configured to prevent engagement and/ordisengagement while the motor shaft of the prime mover is rotating(e.g., when an operator attempts to adjust the hydraulic levers and/orremote instructions are received) in instances the engagement couplingis configured to only perform static engagement and/or disengagement.

FIG. 12 is a flow chart of an embodiment of a method 1200 to pumpfracturing fluid into a wellhead. Method 1200 starts at block 1202 andreceives electric power to power at least one prime mover. The primemover may be a dual-shaft electric motor located on a fracturing pumptransport as shown in FIGS. 7A and 7B. Method 1200 may then move toblock 1204 and receive fracturing fluid produced from one or moreblenders. In one embodiment, the blenders may be electric blenders thatincludes enclosed mixer hoppers.

Method 1200 then moves to block 1206 and drives one or more pumps usingthe at least one prime mover to pressurize the fracturing fluid. In oneembodiment, the pumps may be positioned on opposite sides and may beboth driven by a single shaft from the dual-shaft electric motor whenthe engagement couplings for both pumps are in engagement position. Inother words, when two pumps are operating and engaged, method 1200 maydrive the two pumps in a parallel configuration instead of a serialconfiguration. If one of the pumps are removed and/or disengaged, method1200 may continue to drive the remaining pump. Method 1200 may receiveengagement and/or disengagement instructions manually and/or from aremote location to engage and/or disengaged the pumps prior to or whiledriving the pumps. Method 1200 may then move to block 1208 and pump thepressurized fracturing fluid into a wellhead.

Blender Transport

FIGS. 8A and 8B are schematic diagrams of an embodiment of a blendertransport 800 that includes an electric blender 806. FIG. 8A illustratesa top-down view of the blender transport 800 and FIG. 8B illustrates aside-profile view of the blender transport 800. The blender transport800 may be powered by the mobile source of electricity as described inFIGS. 1-6. The electric blender 806 may be a dual configuration blender,as described in U.S. Patent Application Publication 2012/0255734, with ablending capacity of about 240 bpm. The dual configuration blender maycomprise electric motors for all rotating machinery and may be mountedon a single transport. The dual configuration blender may have twoseparate blending units that are configured to be independent andredundant. For example, any one or both the blending units may receive asource fluid via inlet manifolds of the blending units. The source fluidmay originate from the same source or different sources. The sourcefluid may subsequently be blended by any one or both of the blending tuband subsequently discharged out of any one or both outlet manifolds ofthe blending units. Other embodiments of the blender transport 800 maybe single configuration blender that includes a single blending unit.

FIGS. 8A and 8B illustrate a “lay-down” trailer 802 design that providesmobility and improves ergonomics for the crew members that performroutine maintenance and operations of the electric blender 806 as the“lay-down” positions the blender tubs, pumps and piping lower to theground level and the main trailer beams are resting on the ground foroperational mode.

Similar to the “lay-down” trailer 710, the “lay-down” trailer 802 maycomprise an upper section above the trailer axles and a lower sectionbelow the trailer axles. In one embodiment, the electric blender 806 andassociated equipment on the trailer may be controlled and monitoredremotely via a control system network. As shown in FIGS. 8A and 8B, ablender control system 804 that comprises a PLC, transformers and one ormore variable frequency drives are mounted on upper section of theblender transport 800. To provide remote control and monitoringfunctions, the network may interface and communicate with the PLC (e.g.,provide operating instructions), and the PLC may subsequently controlone or more variable frequency drives mounted on the blender trailer todrive one or more electric motors of the blender. Operating the blendertransport 800 remotely may eliminate equipment operators from beingexposed to hazardous environment and avoiding potential exposureconcentrated chemicals, silica dust, and rotating machinery. Forexample, a conventional blender transport typically includes a stationfor an operator to manually operate the blender. By remotely controllingusing the control network and blender control system 804, the stationmay be removed from the blender transport 800. Recall that a data vanmay act as a hub to provide the remote control and monitoring functionsand instructions to the blender control system 804.

FIGS. 9A and 9B are schematic diagrams of an embodiment of a blendertransport 900 that includes an electric blender 902 with enclosed mixerhoppers 904. FIG. 9A illustrates a top-down view of the blendertransport 900 and FIG. 9B illustrates a side-profile view of the blendertransport 900. The electric blender 902 is substantially similar to theelectric blender 806 except that the electric blender 902 uses enclosedmixer hoppers 904 to add proppants and additives to the blending tub.FIGS. 9A and 9B illustrate that the electric blender 902 is a dualconfiguration blender that includes two enclosed mixer hoppers 904powered by two electric motors, where each of the electric motors mayoperate an enclosed mixer hopper 904.

Blenders that comprises open hoppers and augers typically have theproppants (e.g., sand) and/or additives exposed to the weather elements.In situations where precipitation occurs at the well site, operators maycover the open hoppers and augers with drapes, tarps, and/or othercoverings to prevent the precipitation from contaminating the proppantsand/or additives. The enclosed mixer hopper 904 replaces the open hopperand augers typically included in a blender (e.g., electric blender 806in FIGS. 8A and 8B) with enclosed mixer hoppers 904 (FIGS. 9A and 9B).By replacing the open hopper and augers with enclosed mixer hoppers 904the blender transport 900 may have the advantages of dust freevolumetric proppant measurement, dust free mixing of proppant andadditives, moderate the transport of proppants, perform accuratevolumetric measurements, increase proppant transport efficiency with lowslip, prevent proppant packing from vibration, produce a consistentvolume independent of angle of repose, and meter and blend wet sand.Other advantages include the removal of gearboxes and increasing safetyfor operators with the enclosed drum.

Control Network System

FIG. 10 is a schematic diagram of an embodiment of a control networksystem 1000 used to monitor, control, and communicate with a variety ofcontrol systems located at one or more well sites. FIG. 10 illustratesthat the control network system 1000 may be in a ring-topology thatinterconnects the control center 1002, blender transports 1004, chemicaladditive unit 1006, hydration unit 1008, and fracturing pump transports1012. A ring topology network may reduce the amount of control cablingused for fracturing operations and increase the capacity and speed ofdata transfers and communication. Additionally, the ring topology mayallow for two way communication and control by the control center 1002for equipment connected to the control network system 1000. For example,the control center may be able to monitor and control the otherfracturing equipment 1010 and third party equipment 1014 when added tothe control network system 1000, and for multiple pieces of equipment tocommunicate with each other. In other network topologies, such as a staror mesh topology, the other fracturing equipment 1010 and third partyequipment 1014 may be limited to one way communication where data istransmitted from the fracturing equipment 1010 and/or third partyequipment 1014 to the control center 1002, but not vice versa or betweendifferent pieces of equipment.

In one embodiment, the control network system 1000 may be a network,such as an Ethernet network that connects and communications with theindividual control systems for each of the fracturing equipment. Thecontrol center 1002 may be configured to monitor, control, and provideoperating instructions to the different fracturing equipment. Forexample, the control center 1002 may communicate with the VFDs locatedwithin the drive power transports 104 that operate and monitor thehealth of the electric motors used to drive the pumps on the fracturingpump transports 108. In one embodiment, the control center 1002 may beone or more data vans. More data vans may be used when the fracturingoperations include fracturing more than two wellheads simultaneously.

At least one embodiment is disclosed and variations, combinations,and/or modifications of the embodiment(s) and/or features of theembodiment(s) made by a person having ordinary skill in the art arewithin the scope of the disclosure. Alternative embodiments that resultfrom combining, integrating, and/or omitting features of theembodiment(s) are also within the scope of the disclosure. Wherenumerical ranges or limitations are expressly stated, such expressranges or limitations may be understood to include iterative ranges orlimitations of like magnitude falling within the expressly stated rangesor limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.;greater than 0.10 includes 0.11, 0.12, 0.13, etc.). The use of the term“about” means ±10% of the subsequent number, unless otherwise stated.

Use of the term “optionally” with respect to any element of a claimmeans that the element is required, or alternatively, the element is notrequired, both alternatives being within the scope of the claim. Use ofbroader terms such as comprises, includes, and having may be understoodto provide support for narrower terms such as consisting of, consistingessentially of, and comprised substantially of. Accordingly, the scopeof protection is not limited by the description set out above but isdefined by the claims that follow, that scope including all equivalentsof the subject matter of the claims. Each and every claim isincorporated as further disclosure into the specification and the claimsare embodiment(s) of the present disclosure.

While several embodiments have been provided in the present disclosure,it should be understood that the disclosed systems and methods might beembodied in many other specific forms without departing from the spiritor scope of the present disclosure. The present examples are to beconsidered as illustrative and not restrictive, and the intention is notto be limited to the details given herein. For example, the variouselements or components may be combined or integrated in another systemor certain features may be omitted, or not implemented.

In addition, techniques, systems, subsystems, and methods described andillustrated in the various embodiments as discrete or separate may becombined or integrated with other systems, modules, techniques, ormethods without departing from the scope of the present disclosure.Other items shown or discussed as coupled or directly coupled orcommunicating with each other may be indirectly coupled or communicatingthrough some interface, device, or intermediate component whetherelectrically, mechanically, or otherwise.

What is claimed is:
 1. A system for pumping and pressurizing fracturingfluid, comprising: a mobile transport; an electric prime mover mountedon the mobile transport; a fracturing pump mounted on the mobiletransport; an engagement panel configured to receive a remote command todisengage the fracturing pump from the electric prime mover; and a driveline assembly comprising an engagement coupling configured to disengagethe fracturing pump and a shaft of the electric prime mover triggered bythe engagement panel in response to receiving the remote command.
 2. Thesystem of claim 1, wherein the electric prime mover is a dual shaftelectric prime mover that extends the shaft out on opposites sides ofthe dual shaft electric prime mover.
 3. The system of claim 2, furthercomprising a second fracturing pump mounted on the mobile transport anda second drive line assembly that comprises a second engagement couplingconfigured to selectively disengage the second fracturing pump and thedual shaft electric prime mover.
 4. The system of claim 1, wherein thedrive line assembly comprises a keyed shaft, and wherein the engagementcoupling is configured to selectively disengage the keyed shaft with theshaft.
 5. The system of claim 4, wherein the drive line assemblycomprises a fixed coupling that couples a pinion shaft of the fracturingpump to the keyed shaft.
 6. The system of claim 1, further comprising amonitoring station mounted on the mobile transport and configured totransmit the remote command to the engagement panel.
 7. The system ofclaim 1, wherein the engagement coupling is configured to selectivelydisengage when the shaft is rotating.
 8. The system of claim 1, whereinthe engagement coupling is configured to selectively disengage after theshaft stops rotating.
 9. The system of claim 1, wherein the fracturingpump includes a dual-pinion shaft.
 10. The system of claim 1, furthercomprising a second fracturing pump mounted on the mobile transport,wherein the fracturing pump and the second fracturing pump each comprisea fluid end assembly that are mounted on a same side of the mobiletransport.
 11. A fracturing pump transport comprising: a firstfracturing pump; a second fracturing pump; a dual shaft electric motorthat comprises a shaft having a first end and a second end; a firstdrive line assembly that comprises a first engagement coupling thatallows for selective engagement, disengagement, or both of the firstfracturing pump with the first end of the shaft; a second drive lineassembly that comprises a second engagement coupling that allows forselective engagement, disengagement, or both of the second fracturingpump with the second end of the shaft; and an engagement panel thatallows for selective engagement or disengagement at the first engagementcoupling based on receiving a remote command.
 12. The fracturing pumptransport of claim 11, wherein the first drive line assembly comprises akeyed shaft, and wherein the engagement coupling allows for selectiveengagement, disengagement, or both of the keyed shaft with the first endof the shaft.
 13. The fracturing pump transport of claim 12, wherein thefirst drive line assembly comprises a fixed coupling that couples thefirst fracturing pump to the keyed shaft.
 14. The fracturing pumptransport of claim 11, wherein the engagement coupling allows forselective engagement, disengagement, or both after the shaft stopsrotating.
 15. The fracturing pump transport of claim 11, wherein thefirst fracturing pump includes a dual pinion shaft.
 16. The fracturingpump transport of claim 11, wherein the first fracturing pump and thesecond fracturing pump each comprise a fluid end assembly that face asame side of the fracturing pump transport.
 17. A method for pumping andpressurizing fracturing fluid, the method comprising: receiving adisengagement command from a location remote to a fracturing pumptransport; disengaging, in response to receiving the disengagementcommand, a first fracturing pump mounted on the fracturing pumptransport with a dual shaft electric prime mover mounted on thefracturing pump transport using a first drive line assembly, wherein thefirst drive line assembly comprises an engagement coupling that allowsfor selective engagement between the first fracturing pump and the dualshaft electric prime mover; and driving a second fracturing pump mountedon the fracturing pump transport with the dual shaft electric primemover after disengaging the first fracturing pump from the dual shaftelectric prime mover using the first drive line assembly.
 18. The methodof claim 17, further comprising: receiving a second disengagementcommand from the location remote to the fracturing pump transport; anddisengaging, in response to receiving the second disengagement command,the second fracturing pump with the dual shaft electric prime moverusing a second drive line assembly, wherein the second drive lineassembly comprises a second engagement coupling that allows forselective engagement between the second fracturing pump and the dualshaft electric prime mover.
 19. The method of claim 18, wherein thedis-engaging of the second fracturing pump with the dual shaft electricprime mover occurs after the dual shaft electric prime mover stopsdriving the second fracturing pump.
 20. The method of claim 17, whereinthe first fracturing pump and the second fracturing pump each comprise afluid end assembly mounted on a same side of the fracturing pumptransport.